EEA Database on Distributed Generation

WHAT'S NEW:

No recent state activity has been identified.

Typically units that emit less than 1 tpy of criteria pollutants are exempt from the permitting process. However, a PM-10 limit of 0.5 tons/yr applies in the Medford Air Quality Maintenance Area (AQMA).

Typically Achievable Control Technology (TACT) typically applies to existing m inor sources with emissions above 5 tons per year of particulate or 10 tons per year of any gaseous pollutant; and new or modified sources with emissions above 1 tpy in any area, or above 500 lbs/yr in a PM-10 nonattainment area.

MINOR SOURCE PERMITTING

Oregon 's Administrative Rules can be accessed from here.

The state has a general permit for electrical power production, stationary or portable facilities up to 25 MW, permit number AQGP-018. A detailed explanation of the permit is available by clicking here . The general permit is set to expire on 8/1/2011. However the general permit is not available for turbines and units burning natural gas. These units must obtain a standard minor source permit. A typical minor source permit requires low NOx burning technology, but requirements could vary depending on the unit and location. In addition new sources are limited to 20% opacity (existing sources to 40%); and for new sources 0.1 grains per dry cubic foot of PM and 0.2 for existing sources.

Plant site emissions must not exceed the following:

NOx, SO2, VOC	39 tpy
CO	99 tpy
PM	24 tpy
PM-10	14 tpy

In addition, the following SO2 Emission Standards are in place:

For new sources with fuel burning equipment having a heat input capacity between 150 MMBtu/hr and 250 MMBtu/hr emissions cannot be in excess of:

1.4 lb/MMBtu heat input, maximum 3-hr average, when liquid fuel is burned;
1.6 lb/MMBtu heat input, maximum 3-hour average, when solid fuel is burned.

For fuel burning equipment with a heat capacity of more than 250 MMBtu/hr the limits are as follows:

0.8 lb/MMBtu heat input, maximum 3-hour average, when liquid fuel is burned;
1.2 lb/MMBtu heat input, maximum 3-hour average, when solid fuel is burned.

MAJOR NSR/PSD PERMITTING

250 tons of any criteria pollutant triggers PSD. 100 tons per year if the source is listed under EPA guidelines.

TREATMENT OF EMERGENCY ENGINES

There are no specific limits but the general operating limits designated by the EPA are 500 hrs/year.

SITING REQUIREMENTS FOR NON-UTILITY GENERATORS:

Before a large energy facility is built in Oregon, the developer must apply for a site certificate from the Energy Facility Siting Council. The types of energy facility subject to Council jurisdiction are defined by statute in ORS 469.300(9). The Council performs a consolidated review for the following energy facilities:

Electric power plants with a nominal electric generating capacity of 25 megawatts or more from thermal power or combustion turbines.
Electric power plants with an average electric generating capacity of 35 megawatts or more if the power is produced from geothermal, solar or wind energy at a single energy facility or within a single energy generation area.
Synthetic fuel plants that convert a natural resource including, but not limited to, coal or oil to a gas, liquid or solid product intended to be used as a fuel and capable of being burned to produce the equivalent of 2 billion Btu of heat a day (except plants that use biomass as the raw material)
Plants that convert biomass to a gas, liquid or solid fuel product, or combination of products, intended to be used as a fuel if any one of such products is capable of being burned to produce the equivalent of six billion Btu of heat a day.
Small generating plants within an energy generation area, as described in OAR 345-001-0200, if the accumulated effects of development are similar to a single plant with an average electric generating capacity of 35 MW or more.

"Nominal electric generating capacity" means the maximum net electric power output of an energy facility based on the average temperature, barometric pressure and relative humidity at the site during the times of the year when the facility is intended to operate. "Average electric generating capacity" means the peak generating capacity of the facility divided by one of the following factors: (a) For wind or solar energy facilities, 3.00; (b) For geothermal energy facilities, 1.11; or (c) For all other energy facilities, 1.00.

Detailed information about the siting process can be found at Oregon Department of Energy Siting Facility Process

BUILDING, ZONING AND FIRE CODES:

Building Codes: Oregon has adopted the 2007 Oregon Structural Specialty Code (OSSC) to govern commercial buildings. It is based on the 2006 IBC and includes state-specific amendments.

Building Codes Division

Energy Codes : Chapter 13 of the OSSC gives mandatory energy efficiency building requirements for non-residential buildings. The requirements meet or exceed ASHRAE 90.1-2004, but do not directly reference it.

Oregon Department of Energy

Fire Codes: Oregon enforces its 2007 Oregon Fire Code, which is based on the 2006 IFC with some amendments.

State Fire Marshal

Zoning: Zoning and planning happens at the local level. Check with each jurisdiction regarding their zoning codes.

Resources (information may not be as current as provided above)

A general overview of each state’s enacted codes can be found HERE.

The International Code Council Adoption page gives state-by-state adoption status of specific ICC codes, as well as information about code adoption by some municipal governments within that state.

Information about energy codes can be found at the DOE’s Building Codes for Energy Efficiency page or at the Building Codes Assistance Project.

INTERCONNECTION REQUIREMENTS:

In July 2007 Oregon established separate rules for net-metering and interconnection for customers of Portland General Electric (PGE) and PacifiCorp, the two primary investor-owned utilities, and municipal utilities and electric cooperatives. Customers of Idaho Power are subject to the rules adopted by the Idaho Public Utilities Commission.

For PGE and PacifiCorp the limits on net-metering are 25 kW capacity for residential generators and 2 MW for non-residential. Systems that generate electricity using solar power, wind power, hydropower, fuel cells or biomass resources are eligible, and those that are net-metered must be intended primarily to offset part or all of a customer’s requirements for electricity.

The PUC rules have three levels of interconnection review. Level 1 applies to certified, inverter-based systems with up to a 25 kW capacity that comply with IEEE standards and UL 1741. Utilities may not charged application or other fees for Level 1 review. Level 2 applies to certified 2 MW capacity systems that also comply with IEEE standards and UL 1741, but do not qualify for Level 1. Utilities may charge fees of up to $50 plus $1 per kW of system capacity. Level 3 review is for those systems that don’t qualify for Level 1 or 2. Utilities may charge fees of up to $100 plus $2 per kW of system capacity, plus charges for time spent on any required impact or facilities studies. For both Level 2 and 3 costs for engineering work performed as part of a review study are limited to $100 per hour.

Municipal utilities, electric cooperatives, and people’s utility district’s must offer customers net-metering to systems that generate using solar power, wind power, hydropower, fuel cells or biomass resources, pursuant to OR Revised Statutes 757.300 Systems must be intended to offset some or all of a customer’s electricity requirements. The aggregated capacity of all net-metered systems is limited to 0.5% of a utility's historic single-hour peak load.

For more information contact your electricity generation and transmission utility or the PUC.

Public Utility Commission of Oregon
550 Capitol Street N.E. Suite 215
Salem, Oregon 97301-2551
puc.commission@state.or.us

EXIT FEES:

Oregon has no statewide policy on exit fees, however according to the PUC there are no exit fees for DG applications.

UTILITY STANDBY RATES:

Oregon does not have a statewide policy on standby rates. Relevant provisions for Oregon utilities are summarized below.

PacifiCorp - Schedule 47: Standby service under 1000 kW is provided under the regular rate that is applicable to the facility. For standby service over 1000 kW, there is a small reservation charge that is assessed every month, with actual usage being assessed under moderate demand and energy charges. Billing demand is based on the average of the two greatest demands of the previous 12 months. Rates are available at: http://www.pacificorp.com/New_Auto_Index/New_Auto_Index2027.html

Portland General Electric Company - Schedule 75: Customers seeking standby service would be provided for under the partial requirements rate that requires the customer to enter into a contract for a set amount of reserve capacity in case the customer's equipment is not functioning. To qualify for this rate customer generation equipment must exceed 2 MW of capacity. Sites are billed through a moderate customer charge and demand based reservation and distribution charges. Moderate energy charges are assessed. There is no demand ratchet. For customers with generation capacity below 2 MW, a contract with the utility would be established to be charged under a rate of PGE's choosing. Rates are available at: http://www.portlandgeneral.com/about_pge/regulatory_affairs/tariffs/rate_schedules.asp?bhcp=1

Oregon

WHAT'S NEW:

AIR EMISSIONS REGULATIONS:

BUILDING, ZONING AND FIRE CODES:

EXIT FEES: